U.S. patent number 10,001,613 [Application Number 14/628,732] was granted by the patent office on 2018-06-19 for methods and cables for use in fracturing zones in a well.
This patent grant is currently assigned to SCHLUMBERGER TECHNOLOGY CORPORATION. The grantee listed for this patent is Schlumberger Technology Corporation. Invention is credited to Sheng Chang, Maria Grisanti, David Kim, Joseph Varkey, Paul Wanjau.
United States Patent |
10,001,613 |
Varkey , et al. |
June 19, 2018 |
Methods and cables for use in fracturing zones in a well
Abstract
A cable having a cable core for use in fracturing zones in a
well, wherein the cable core includes an optical fiber conductor.
The optical fiber conductor has a pair of half-shell conductors. An
insulated optical fiber located between the pair of half-shell
conductors. The insulated optical fiber is coupled with the pair of
half-shell conductors. An optical fiber conductor jacket is
disposed about the pair of half-shell conductors.
Inventors: |
Varkey; Joseph (Missouri City,
TX), Wanjau; Paul (Missouri City, TX), Kim; David
(Stafford, TX), Grisanti; Maria (Missouri City, TX),
Chang; Sheng (Sugar Land, TX) |
Applicant: |
Name |
City |
State |
Country |
Type |
Schlumberger Technology Corporation |
Sugar Land |
TX |
US |
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Assignee: |
SCHLUMBERGER TECHNOLOGY
CORPORATION (Sugar Land, TX)
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Family
ID: |
55166630 |
Appl.
No.: |
14/628,732 |
Filed: |
February 23, 2015 |
Prior Publication Data
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Document
Identifier |
Publication Date |
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US 20160025945 A1 |
Jan 28, 2016 |
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Related U.S. Patent Documents
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Application
Number |
Filing Date |
Patent Number |
Issue Date |
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62027696 |
Jul 22, 2014 |
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Current U.S.
Class: |
1/1 |
Current CPC
Class: |
E21B
43/26 (20130101); H01B 3/47 (20130101); E21B
47/07 (20200501); H01B 7/046 (20130101); G02B
6/4416 (20130101); H01B 3/30 (20130101); G02B
6/504 (20130101); G02B 6/443 (20130101); H01B
9/005 (20130101) |
Current International
Class: |
G02B
6/44 (20060101); H01B 3/47 (20060101); H01B
7/04 (20060101); E21B 47/06 (20120101); H01B
3/30 (20060101); E21B 43/26 (20060101); G02B
6/50 (20060101); H01B 9/00 (20060101) |
References Cited
[Referenced By]
U.S. Patent Documents
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WO |
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WO2009088317 |
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Jul 2009 |
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WO |
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WO2012058296 |
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WO |
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WO2012170382 |
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Apr 2015 |
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WO |
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Primary Examiner: Gay; Jennifer H
Attorney, Agent or Firm: Hinkley; Sara K. M.
Parent Case Text
CROSS-REFERENCE TO RELATED APPLICATIONS
This Application claims the benefit of U.S. Provisional Patent
Application No. 62/027,696 that was filed on Jul. 22, 2014 and is
entitled "Methods and Cables for Use in Fracturing Zones in a
Well". U.S. Provisional Patent Application No. 62/027,696 is
incorporated in it entirety herein by reference.
Claims
What is claimed is:
1. A cable for monitoring downhole fracturing operation,
comprising: a. an optical fiber conductor comprising two shaped
wires and at least one optical fiber located therein, wherein the
optical fiber is coupled with the two shaped wires; b. a double
jacket, comprising two polymers of differing strength; c. inner
wires helically wound about the double jacket; d. an insulation
layer disposed about the inner wires; e. a first jacket disposed
about the insulating layer; f. a first layer of strength members
disposed about the first jacket; g. a second jacket disposed about
the first layer of strength members; h. a second layer of strength
members disposed about the second jacket; and i. an outer jacket
disposed about the second layer of strength members.
2. The cable of claim 1, wherein the first jacket is a fiber
reinforced polymer.
3. The cable of claim 1, wherein the outer jacket is a fiber
reinforced polymer.
4. The cable of claim 1, wherein the second layer of strength
members is at least partially embedded into the second jacket.
5. The cable of claim 1, wherein the first layer of strength
members is at least partially embedded into the first jacket.
6. The cable of claim 1, wherein the two shaped wires are used to
provide data, power, heat or combinations thereof.
Description
FIELD OF THE DISCLOSURE
The disclosure generally relates to methods and cables for use in
fracturing zones in a well.
BACKGROUND
Zones in a well are often fractured to increase production and/or
allow production of hydrocarbon reservoirs adjacent a well. To
ensure proper fracturing of zones it is useful to monitor the
fracturing operations.
SUMMARY
An example cable for use in fracturing zones in a well includes a
cable core. The cable core includes an optical fiber conductor. The
optical fiber conductor includes a pair of half-shell conductors.
An insulated optical fiber is located between the pair of
half-shell conductors. The insulated optical fiber is coupled with
the pair of half-shell conductors. The optical fiber conductor also
includes an optical fiber conductor jacket disposed about the pair
of half-shell conductors.
An example of a system for monitoring fracturing operations
includes a cable. The cable comprises a cable core having an
optical fiber conductor. The optical fiber conductor includes a
pair of half-shell conductors. An insulated optical fiber is
located between the pair of half-shell conductors. The insulated
optical fiber is coupled with the pair of half-shell conductors,
and an optical fiber conductor jacket is disposed about the pair of
half-shell conductors. A tool string is connected with the cable,
and the tool string has an anchor.
An example method of fracturing a well includes conveying a cable
and tool string into a well to a first zone adjacent a heel of a
horizontal portion of the well. The method also includes anchoring
the cable and tool string in the well. The method also includes
applying fracturing fluid to the first zone, and monitoring the
fracturing by using the an optical fiber conductor of the cable to
acquire cable temperature data, temperature increase and decrease
data, vibration data, strain data, or combinations thereof.
BRIEF DESCRIPTION OF THE DRAWINGS
FIG. 1 depicts a schematic of an optical fiber conductor.
FIG. 2 depicts a cable for use in fracturing operations according
to one or more embodiments.
FIG. 3 depicts a schematic of another cable for use in fracturing
operations according to one or more embodiments.
FIG. 4 depicts a schematic of a cable for use in fracturing
operations according to one or more embodiments.
FIG. 5 depicts a schematic of a cable for use in fracturing
operations according to one or more embodiments.
FIG. 6A depicts an example system for monitoring fracturing
operations according to one or more embodiments.
FIG. 6b depicts another example system for use in well to perform
operations on the well.
FIG. 7 depicts an example method of fracturing zones in a well
according to one or more embodiments.
FIG. 8 depicts an example method of placing a cable in well for
monitoring.
FIG. 9 depicts an example method of placing a cable in a well for
hydraulic fracturing and logging in a horizontal well.
FIG. 10 depicts an example cable with a hepta core for monitoring
in a well.
DETAILED DESCRIPTION
Certain examples are shown in the above-identified figures and
described in detail below. In describing these examples, like or
identical reference numbers are used to identify common or similar
elements. The figures are not necessarily to scale and certain
features and certain views of the figures may be shown exaggerated
in scale or in schematic for clarity and/or conciseness.
An example cable for use in fracturing zones in a well includes a
cable core that has an optical fiber conductor. The optical fiber
conductor includes a pair of half-shell conductors. The half-shell
conductors can be made from any conductive material. Illustrative
conductive materials include copper, steel, or the like. The
half-shell conductors can be used to provide data, power, heat or
combinations thereof. The material of the conductors can be
selected to accommodate the desired resistance of the cable. The
half-shell conductors can be used to provide heat, and the heating
of the cable can be controlled by selective adjustment of current
passing through the half-shell conductors.
An insulated optical fiber is located between the pair of
half-shell conductors. The insulated optical fiber can be insulated
with a polymer or other insulating material. The insulated optical
fiber can be coupled with the pair of half-shell conductors. For
example, the insulation of the optical fiber can be bonded with the
optical fiber and the inner surfaces of the half-shell conductors.
Coupled as used herein can mean physically connected or arranged
such that stress or force applied to the half-shell conductors is
also applied to the optical fiber. For example, the space between
the insulated optical fiber and the half-shell conductors can be
minimal to allow coupling of the insulated optical fiber and
half-shell conductors. The optical fiber can be a single optical
fiber or a plurality of optical fibers. The optical fiber can be a
bundle of optical fibers.
An optical fiber conductor jacket can be disposed about the pair of
half-shell conductors. The optical fiber conductor jacket can be
made from polymer or other materials.
An example cable core can also include a plurality of optical fiber
conductors and cable components located in interstitial spaces
between the plurality of optical fiber conductors. The cable
components can be glass-fiber yarn, polymer, polymer covered metal
tubes, composite tubes, metal tubes, or the like. A central cable
component can be located between the plurality of optical fiber
conductors. In one or more embodiments, a non-conductive material
can be located in the cable core to fill void spaces therein.
A foamed-cell polymer, a core jacket, an outer jacket, or
combinations thereof can be located about the cable core. The core
jacket can be a polymer, a fiber reinforced polymer, a cabling
tape, or combinations thereof.
In one or more embodiments, a seam-weld tube can be located about
an outer jacket. The seam-welded tube can at least partially embed
into the outer jacket.
FIG. 1 depicts a schematic of an optical fiber conductor. The
optical fiber conductor 100 has a first half-shell conductor 110, a
second half-shell conductor 112, an insulated optical fiber 114,
and an optical fiber conductor jacket 116.
FIG. 2 depicts a cable for use in fracturing operations according
to one or more embodiments. The cable 200 includes a plurality of
optical fiber conductors 100, a plurality of cable components 210,
a core jacket 220, a non-conductive material 230, a foamed-cell
polymer 240, an outer jacket 250, and a seam-welded tube 260.
The plurality of optical fiber conductors 100 and the plurality of
cable components 210 are cabled about a central cable component
212. The non-conductive material 230 is used to fill spaces or
voids in the cable core during cabling. The core jacket 220 is
extruded or otherwise placed about the plurality of optical fiber
conductors 100, the cable components 220, the central cable
component 212, and the non-conductive material 230.
The foamed-cell polymer 240 is placed about the core jacket 220,
and an outer jacket 250 is placed about the foamed-cell polymer
240. A seam-welded tube 260 is placed about the outer jacket 250.
The seam-welded tube 260 can at least partially embed into the
outer jacket 250. For example, a weld bead can embed into the outer
jacket 250.
The cable 200 can be connected to a downhole tool and can be
arranged to heat and power delivery. For example, a power source at
surface can be connected with two of the optical fiber conductors
100, such that one is positive and the other is negative, the third
can be used for grounding or floating. The paths can be in a series
loop for heating application, and when power needs to be delivered
to downhole tools a switch can open the series conductor path and
connect each path to designated tool circuit for power
delivery.
The self-heating and power supply can be performed concurrently.
For example, one conductor can be connected to positive terminal at
a power supply at surface and to a designated tool circuit
downhole, and another conductor can be connected to a negative
terminal at the surface and to a designated tool circuit downhole.
Accordingly, power can be delivered downhole and one of the
conductor paths can be a return; in one embodiment, if the downhole
tool is a tractor, the tractor can be stopped and the wheels closed
allowing power to be delivered without movement and at same time
the self-heating can occur.
FIG. 3 depicts a schematic of another cable for use in fracturing
operations according to one or more embodiments. The cable 300
includes the plurality of optical fiber conductors 100, the
plurality of cable components 210, the center component 212, the
core jacket 220, the non-conductive material 230, the foamed-cell
polymer 240, the outer jacket 250, the seam-welded tube 260, a
reinforced jacket 310, an additional jacket 320, and an additional
seam-welded tube 330.
FIG. 4 depicts a schematic of a cable for use in fracturing
operations according to one or more embodiments. The cable 400
includes a plurality of optical fiber conductors 100, the plurality
of cable components 210, the core jacket 220, a first jacket 420, a
first layer of strength members 410, a second jacket 422, a second
layer of strength members 430, a third jacket 424, and a reinforced
outer jacket 440.
The plurality of optical fiber conductors 100 and the plurality of
cable components 210 can be cabled about the central component 212.
The non-conductive material 230 is used to fill spaces or voids in
the cable core during cabling. A core jacket 220 is extruded or
otherwise placed about the plurality of optical fiber conductors
100, the cable components 220, the central cable component 212, and
the non-conductive material 230. A first jacket 420 can be placed
about the cable core jacket 220. The first jacket 420 can be a
reinforced polymer, a pure polymer, or the like.
The first layer of strength members 410 can be cabled about the
first jacket 420. The first layer of strength members 410 can at
least partially embed into the first jacket 420. A second jacket
422 can be placed about the first layer of strength members 410.
The second jacket 422 can at least partially bond with the first
jacket 420. A second layer of strength members 430 can be cabled
about the second jacket 422. The second jacket 422 can separate the
first layer of strength members 410 from the second layer of
strength members 430 from each other. The strength members in the
first strength member layer and the second strength member layer
can be coated armor wire, steel armor wire, corrosion resistant
armor wire, composite armor wire, or the like.
A third jacket 424 can be placed about the second layer of strength
members 420. The third jacket 424 can bond with the second jacket
422. A reinforced outer jacket 430 can be placed about the third
jacket 424.
The quad type cable can be connected to a tool string using a 1 by
1 configuration, a 2 by 2 configuration, or a 3 by 1 configuration.
For example, a series loop can be formed by connecting two
conductors to positive and two conductors to negative in a closed
loop and a switching device can be used to open the loop and
connect with the downhole tools. In another configuration two of
the conductors can be looped for heat generation and two of the
conductors can be connected to the downhole tools for power
deliver; if the downhole tool is a tractor, the tractor can be
stopped and the wheels closed allowing power to be delivered
without movement and at same time the self-heating can occur.
In one example, two conductor paths can be connected to power at
surface and a third to negative at surface, and each of the
conductors can be connected to designated tool circuits downhole
for power delivery using one of the conductive paths as a
return.
FIG. 5 depicts cable according to one or more embodiments. The
cable 500 includes one or more optical fiber conductors 100, a
double jacket 510, wires 520, an insulating layer 530, a first
jacket 540, a first layer of strength members 550, a second jacket
560, a second layer of strength members 570, a third jacket 580,
and an outer jacket 590.
The optical fiber conductor 100 has the double jacket 510 located
thereabout. The double jacket can include two polymers of differing
strength. The wires 520 can be served helically over the double
jacket 510. The insulating layer 530 can be placed about the wires
520. The insulating layer can be a polymer or like material. The
first jacket 540 can be placed about the insulating layer. The
first jacket 540 can be a fiber reinforced polymer.
The first strength member layer 540 can be cabled about the first
jacket 540. The first strength member layer 540 can at least
partially embed into the first jacket 540. The second jacket 560
can be placed about the first strength member layer 540. The second
jacket 560 can bond with the first jacket 540.
The second layer of strength members 570 can be cabled about the
second jacket 560, and the second layer of strength members 570 can
at least partially embed into the second jacket 560.
The third jacket 580 can be placed about the second layer of
strength members 570. The third jacket 580 can bond with the second
jacket 560. The outer jacket 590 can be placed about the third
jacket 580. The outer jacket 580 can be a fiber reinforced
polymer.
FIG. 6A depicts an example system for monitoring fracturing
operations according to one or more embodiments. The system 600
includes a cable 610 and a tool string 620. The tool string 620
includes an anchoring device 622 and a logging tool 624. The cable
610 can be any of those disclosed herein or a cable having an
optical fiber conductor as described herein. The anchoring device
622 can be a centralizer, a spike, an anchor, or the like. The tool
string 620 can have a flow meter and a tension measuring
device.
The cable 610 and tool string 620 can be conveyed into a wellbore
630. The wellbore 630 has a heel 632, a plurality of zones 634, and
a toe 636. The cable 610 and tool string 620 can be conveyed into
the wellbore 630 using any method of conveyance, such as pump down,
tractors, or the like. The tool string 620 can be stopped adjacent
a first zone adjacent the heel 632. Fracturing fluid can be pumped
into the well to open the zone, and the cable 610 can be used to
monitor the fracturing operation. After fracturing, diverter fluid
can be provided to the well to plug the fractures. The tool string
and cable can be conveyed further into the well towards the toe 636
and stopped at intermediate zones. At each of the zones the
fracturing operations and diverting can be repeated.
Once all zones are fractured, the plugged fractures can be
unplugged. The plugged fractures can be unplugged using now known
or future known techniques. The tool string 620 and cable 610 can
be left in the wellbore and the zones can be produced, and the
logging tool 624 can be used to acquire data. In one or more
embodiments, the logging tool 624 can acquire data before the zones
are fractured, as the zones are fractured, after the zones are
fractured, or combinations thereof.
FIG. 6b depicts another example system for use in well to perform
operations on the well. The system includes a tool string 640. The
tool string 640 includes a tractor 642, a logging tool 644, and a
plug 648. The tool string 640 can include other equipment to
perform additional downhole services. The downhole services can
include intervention operations, completion operations, monitoring
operations, or the like. A cable 650 can be connected with the tool
string 640. The cable 650 can be any of those disclosed therein or
substantially similar cables.
FIG. 7 depicts an example method of fracturing zones in a well
according to one or more embodiments.
The method 700 includes conveying a cable and tool string into a
well to a first zone adjacent a heel of a horizontal portion of the
well (Block 710). As the cable and tool string are conveyed into
the well, the tension on the cable and the flow of fluid can be
measured. Fluid flow and cable tension can predict the cable
status. For example, if a high flow rate is measured but the cable
loses tension, it would indicate the cable is buckling or stuck
downhole; if the cable is under tension and low or no flow is
detected, the fractures before the cable anchoring mechanism are
taking most of the fluid; if the cable is under tension and high
flow rate is measured it would indicate that there are no open
fractures before the cable anchoring mechanism and the cable should
be moving towards the toe of the well. The fluid flow can be
measured using a flow meter in the tool string or the self-heated
capability of the cable can be used to predict the flow velocity
around the cable based on the rate of increase or decrease of the
temperature using distributed temperature sensing.
The method can also include anchoring the cable and tool string in
the well (Block 720). The method can also include applying
fracturing fluid to the first zone (Block 730).
The method also includes monitoring the fracturing by using an
optical fiber conductor of the cable to acquire cable temperature
data, temperature increase and decrease data, vibration data,
strain data, or combinations thereof (Block 740). The hydraulic
fracturing process is monitored using the heat-enabled fiber-optic
cable. Real-time measurements of cable temperature, temperature
increase or decrease rate, vibration, and strain measurements are
available to predict which fracture is taking more fluid.
Operations above can be repeated for each zone. Cable tension
measurement and fluid flow can be monitored after each zone to
prevent damage to the cable.
FIG. 8 depicts an example method of placing a cable in well for
monitoring. The method 800 includes conveying a cable and tractor
into a well (Block 810). The conveying can be performed using pump
down, a tractor, gravity, other known or future known methods, or
combinations thereof.
Once the tractor and at least a portion of the cable or located at
a desired location in the well, the method can include anchoring
the tractor in place (Block 820). The tractor can be anchored in
place using anchoring spikes, anchoring pads, or the like.
The method can also include removing slack from the cable after the
tractor is anchored in place (Block 830). The slack can be removed
from the cable by pulling at the surface or using other known or
future know techniques.
The method can also include monitoring the well conditions,
operation parameters, or combinations thereof. The monitoring can
include hydraulic fracturing monitoring, detecting leaks in a
casing, gas production, oil production, electrical submersible pump
monitoring, gas lift mandrel monitoring, injection water
breakthrough, cross flow shut-in, gas breakthrough, injection
profile of water injection wells, steam injection monitoring, CO2
injection performance, zonal isolation monitoring, monitoring for
flow behind casing, or other temporary or permanent monitoring
operations. The cable can acquire data to aid in fracture height
determination, zonal flow contribution determination, evaluation of
well stimulation, optimization of gas lift operations, optimization
of electrical submersible pumps, other wellbore data, operation
data, or production data, or combinations thereof.
The monitoring can be performed in any type of well. Illustrative
wells include subsea wells, vertical wells, and horizontal wells.
The monitoring can be permanent monitoring or temporary
monitoring.
FIG. 9 depicts an example method of placing a cable in a well for
hydraulic fracturing and logging in a horizontal well. The method
900 includes connecting the cable with a plug, tractor, and logging
tool (Block 910). The plug can be a packer or other sealing device.
The tractor can be battery operated or powered by the cable.
The method 900 also includes conveying the tractor, plug, and
logging tool to a desired location within a well (Block 920). The
desired location can be any location in the well. The desired
location can be at the toe of a horizontal portion of the well,
within an intermediate location of a horizontal portion of the
well, or any other portion of the well.
The method also includes anchoring the tractor and removing slack
from the cable (Block 930). The method also includes setting the
plug (Block 940). The plug can isolate the tractor and logging tool
from pressure in the well, corrosive fracturing fluids, or other
wellbore condition uphole of the tractor and logging tool. The
method includes pumping fracturing fluid into the well (Block 950).
The method also includes monitoring the fracturing operation using
the cable (Block 960). The monitoring can include obtaining
real-time measurements of cable temperature, temperature increase
or decrease, vibration, strain measurement, or other
parameters.
The method also includes pumping diverter fluid into the well
(Block 950). The method also includes repeating the fracturing and
pumping of divert fluid until desired state of production is
obtained (Block 970). The method also includes deactivating the
plug and reversing the tractor out of the well (Block 980). The
method also includes logging with the logging tool as the tractor
is reversed out of the well (Block 990).
In one or more embodiments of the method, the method can also
include monitoring production with the cable as the tractor is
reversed out of the well.
In one or more embodiments of the methods disclosed herein the
cable can be connected with the tractor, a perforating gun, a
logging tool, or combinations thereof. For example, the cable can
be connected with a perforating gun and tractor, and the
perforating gun can be used to perforate the well before the well
is fractured. In another example, the cable can be connected with a
perforating gun, tractor, logging tool, and a plug. The well can be
perforated, the plug can be set, fracturing operations carried out,
and logging can be performed as the tractor is reversed out of the
well. Of course, other combinations of downhole hole equipment can
be added to the tool string allowing for real-time monitoring using
the cable and performance of multiple operations to be performed on
a well in a single trip.
FIG. 10 depicts an example cable for monitoring in a well. The
cable 1000 can include a cable core that includes a plurality of
conductors 1100 and a plurality of cable components 1200. The
conductors 1100 can be any conductor. Illustrative conductors
include stranded conductors, fiber optic conductors, other
conductors described herein, other know or future known conductors,
or combinations thereof. The cable components 1200 can be filler
rods, incompressible polymer rods, metallic rods, other now known
or future known components, or any combination thereof.
The cable core can have a first armor layer 1300 and a second armor
layer 1400 disposed thereabout. The armor layers 1300 and 1400 can
include any number of armor wires. The armor layers can be filled
with polymer, and the polymer in each armor layer can be bond
together. In one or more embodiments, a jacket or the like can
separate the first armor layer 1300 from the second armor layer
1400.
For a hepta cable the cable can be connected with the downhole tool
in surface power supply using a 3 by 3 configuration. Three
conductors can be used for power delivery and 3 conductors can be
used for heating. Other configuration can be used. For example, all
conductors can be used for heating by connecting in loop, where
three conductors are connected to positive of power supply and
three conductors are connected to negative of the power supply, and
at the tool string a switch can be used to open the loop and
connect the conductors to the a designated circuit for power
delivery.
In another embodiment, power delivery and heating can be done at
the same time. For example, three conductors can be connected to
positive at the surface and three conductors can be connected to
negative at surface, two or more conductors can be in series for
heating application, and the remaining conductive paths can
connected to designated tool circuit for power delivery using one
conductive path as the return; and when the tractor is stopped the
wheels can be retracted allowing for power delivery while avoiding
movement.
The cables disclosed herein can be connected with downhole tools
and surface power in various ways allowing for continuous power
delivery and heating, selective power delivery and heating, or
combinations thereof. The connections can be made using now known
or future known techniques. The connections can include switches,
microprocessors, or other devices to control power delivery and
heating.
Although example assemblies, methods, systems have been described
herein, the scope of coverage of this patent is not limited
thereto. On the contrary, this patent covers every method, nozzle
assembly, and article of manufacture fairly falling within the
scope of the appended claims either literally or under the doctrine
of equivalents.
* * * * *
References